US4139060A - Selective wellbore isolation using buoyant ball sealers - Google Patents

Selective wellbore isolation using buoyant ball sealers Download PDF

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Publication number
US4139060A
US4139060A US05/850,879 US85087977A US4139060A US 4139060 A US4139060 A US 4139060A US 85087977 A US85087977 A US 85087977A US 4139060 A US4139060 A US 4139060A
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US
United States
Prior art keywords
fluid
density
perforations
ball sealers
casing
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Lifetime
Application number
US05/850,879
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English (en)
Inventor
Thomas W. Muecke
Claude E. Cooke, Jr.
Clay Gruesbeck, Jr.
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
ExxonMobil Upstream Research Co
Original Assignee
Exxon Production Research Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Exxon Production Research Co filed Critical Exxon Production Research Co
Priority to US05/850,879 priority Critical patent/US4139060A/en
Priority to CA308,522A priority patent/CA1081608A/en
Priority to AU38864/78A priority patent/AU514250B2/en
Priority to NO783267A priority patent/NO152467C/no
Priority to NLAANVRAGE7810001,A priority patent/NL174752C/xx
Priority to MX175290A priority patent/MX149571A/es
Priority to DE2848972A priority patent/DE2848972C2/de
Priority to GB8128472A priority patent/GB2085512B/en
Priority to GB7844467A priority patent/GB2007745B/en
Application granted granted Critical
Publication of US4139060A publication Critical patent/US4139060A/en
Priority to NO83833401A priority patent/NO154403C/no
Priority to MY112/85A priority patent/MY8500112A/xx
Priority to MY117/85A priority patent/MY8500117A/xx
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/261—Separate steps of (1) cementing, plugging or consolidating and (2) fracturing or attacking the formation
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/138—Plastering the borehole wall; Injecting into the formation

Definitions

  • This invention pertains to the treating of subterranean formations penetrated by a well. More particularly, the method is directed to a method for selectively treating a plurality of formation intervals using ball sealers.
  • casing a string of pipe, known as casing
  • cement around the outside of the casing to isolate the various hydrocarbon productive formations penetrated by the well.
  • the casing and cement sheath are perforated.
  • a baffle ring which fits between two joints of casing, has a slightly smaller inside diameter than the casing so that a large ball, or bomb, dropped in the casing will seat in the baffle. After the ball is seated in the baffle, the ball prevents fluid flow down the hole.
  • One disadvantage with this method is the extra expense of placing the baffle.
  • the inside diameter of the bottom baffle is so small that a standard perforating gun cannot be used to perforate below the bottom baffle.
  • a bridge plug which is comprised principally of slips, a plug mandrel, and a rubber sealing element, has also been run and set in casing to isolate a lower zone while treating an upper section. After fracturing or acidizing the well, the plug is generally knocked to the well bottom with a chisel bailer.
  • One difficulty with the bridge plug method is that the plug sometimes does not withstand high differential pressures.
  • Another problem with this diverting technique is that placement and removal of the plug can be expensive.
  • ball sealers are pumped into the well along with formation treating fluid.
  • the balls are carried down the wellbore and to the perforations by the fluid flow through the perforations.
  • the balls seat upon the perforations and are held there by the pressure differential across the perforations.
  • Ball sealer diverting techniques have met with considerable usage, the balls often do not perform effectively because only a fraction of the balls injected actually seat on perforations.
  • Ball sealers having a density greater than the treating fluid will often yield a low and unpredictable seating efficiency highly dependent on the difference in density between the ball sealers and the fluid, the flow rate of the fluid through the perforations, and the number, spacing and orientation of the perforations. The net result is that the plugging of the desired number of perforations at the proper time during the treatment is left largely to chance. It is also difficult to control which perforated interval of the perforated casing will receive the balls and in many instances results in undesired stimulation in some portions of the formation.
  • Ball sealers having a density less than the treating fluid have been proposed to improve this seating efficiency problem.
  • treating fluid containing lightweight ball sealers is injected down the well at a rate such that the downward velocity of the fluid is sufficient to impart a downward drag force on the ball sealers greater in magnitude than the upper buoyancy force of the ball sealers.
  • the ball sealers Once the ball sealers have reached the perforations, they all will seat and plug the perforations and cause the treating fluid to be diverted to the remaining open perforations.
  • One problem with using lightweight ball sealers is that if the downward flow of fluid in the casing is slow, which is generally the case with matrix acidizing treatments, the treating fluid may not overcome the upward buoyancy force of the ball sealers and thus the ball sealers may not be transported to the perforations.
  • Another problem is that it is sometimes difficult to control which interval of the formation will be treated. Lightweight balls carried down the casing by the more dense treating fluid often plug the upper perforations before plugging the lower perforations.
  • the present invention provides an improved method for temporarily restricting flow of a treating fluid through lower perforations in a cased wellbore while injecting treating fluid through upper perforations in the cased wellbore.
  • the invention comprises introducing into a well casing which is perforated at a plurality of levels: ball sealers designed to plug at least one of the perforations in the casing; a first fluid having a density greater than the ball sealers density, and a second fluid having a density less than the ball sealers density.
  • the ball sealers, the first fluid or the second fluid may be introduced into the well concurrently or in any order.
  • the first fluid is introduced into the well in an amount sufficient to fill the lower portion of the well to a level between the perforations to be left open and the perforations to be temporarily restricted to fluid flow.
  • the density differential between the ball sealers and the fluids in the well will cause the balls to travel to the interface or transition zone between the first fluid and the second fluid.
  • a treating fluid is injected into the well. Fluid flow through perforations below the ball sealers will carry the ball sealers to the perforations where the ball sealers will seat and divert further injection of treating fluid through the upper perforations. This process may be repeated to treat any number of zones in the formation.
  • the first fluid is an aqueous brine solution having a density greater than about 1.1 g/cc
  • the second fluid is diesel oil having a density less than 0.95 g/cc
  • the ball sealers are made of a syntactic foam core and a polyurethane cover and have a density between about 1.0 g/cc and 1.05 g/cc.
  • This invention permits lightweight ball sealers to be used for restricting flow of treating fluid through perforations in a lower portion of a well with 100% efficiency while not interferring with injection of treating fluid through perforations in an upper portion of a well. This method therefore offers significant advantages over methods used in the prior art for fluid diversion.
  • FIGURE is an elevation view in section of a well illustrating the practice of the present invention.
  • the present invention is applicable in wellbores having a casing arranged therein which penetrates a plurality of hydrocarbon productive intervals, formations, zones or strata. Frequently the oil productive intervals overlie one another and may be separated by non-productive intervals.
  • the interval less resistant to treatment has its permeability or productivity increased while those intervals less susceptible to treatment are not increased in permeability or productivity.
  • One zone is treated in favor of the other.
  • This invention is particularly applicable for increasing the permeability or productivity of an upper productive interval by stimulating methods, such as by hydraulic fracturing or acidizing, while restricting fluid flow into a lower productive interval.
  • FIGURE shows a well 10 having a casing 12 run to the bottom of the wellbore.
  • the well passes through an upper hydrocarbon productive interval 14 and a lower hydrocarbon productive interval 15. It is assumed for this embodiment that the lower interval 15 has a higher permeability than upper interval 14.
  • the casing is shown being bonded to the sides of the borehole by cement around the outside to hold the casing in place and to isolate intervals 14 and 15 penetrated by the well.
  • the cement sheath 13 extends upward from the bottom of the wellbore to the earth's surface.
  • the interval 14 is in fluid communication with the interior of the casing 12 through perforations 17 and interval 15 is in fluid communication with the interior of the casing through perforations 16.
  • Hydrocarbons of producing intervals 14 and 15 flow through the perforations 16 and 17 into the interior of the casing 13 and are transported to the surface through production tubing 19.
  • a production packer is installed near the lower end of the production tubing 19 and above upper interval 14 to achieve a pressure seal between the production tubing 19 and the casing 12.
  • Production tubing is not always used and in those cases the entire interior volume of the casing is used to conduct the hydrocarbons to the surface of the earth. Because lower interval 15 has a higher permeability than upper interval 14 to suitably stimulate the upper interval 14 by fracturing or acidizing, it is necessary to restrict flow of treating fluids into lower interval 15.
  • the first step in isolating lower interval 15 from upper interval 14 in accordance with this invention is to introduce into the wellbore a fluid having density greater than the density of the ball sealers.
  • the dense fluid identified by the numeral 20 in the FIGURE, is pumped into the well in an amount sufficient to fill the lower portion of the wellbore to a level between the perforations 16 of lower interval 15 and perforations 17 of the upper interval 14.
  • the dense liquid 20 used for filling the lower portion of the well should have a density greater than the density of the ball sealers introduced in the well. This is desirable in order that ball sealers will float on the dense fluid 20 above perforations 16.
  • the density of fluid 20 will depend of course on the density of the ball sealers used in the well, but the fluid will normally have a minimum density above 1 gram per cubic centimeter (g/cc) and preferably a density above about 1.10 g/cc. Any liquid that has the requisite density characteristics and is inert with the ball sealers may be used in this invention.
  • Suitable dense fluids may include aqueous fluids including brine solutions and calcium bromide solutions and non-aqueous fluids including ortho-nitrotoluene, carbon disulfide, dimethylphthalate, nitrobenzene and isoquinoline.
  • a fluid having a density less than the density of the ball sealers is introduced into the casing.
  • This light fluid identified by numeral 21 in the FIGURE, will be disposed in the well above the dense fluid and preferably fills the well to a level adjacent perforations 17 of interval 14. Any liquid which has a density less than ball sealers density may be used in this practice of this invention. Suitable light fluids include hydrocarbons such as diesel fuel and light hydrocarbon condensates. The light fluid 21 may also be the same fluid used to treat interval 14 provided the treating fluid density is less than the ball sealers density.
  • ball sealers 22 having a density between the density of dense fluid 21 and light fluid 20 are introduced into the well.
  • These ball sealers are designed to have an outer covering sufficiently compliant to seal a jet formed perforation and to have a solid rigid core which resists extrusion into or through the perforations.
  • the balls are preferably approximately spherical in shape but other geometries may be used. Because of the density differential between the ball sealers and the light fluid 21, the ball sealers will sink to the bottom of light fluid 21 and float to the top of the dense fluid 20.
  • a treating fluid is injected into the well to treat formation 14.
  • the treating fluid may include an acid, water solution, or hydrocarbon solution such that the formation permeability or productivity is increased by physical cracking or fracturing or by reaction of a chemical agent, such as acid, with the formation material.
  • any fluid flow into interval 15 will cause the level of dense fluid 20 to decrease.
  • the density of the treating fluid may be equal to, or greater than, or less than the density of the ball sealers. If the treating fluid has a density greater than the ball sealers, the light fluid 21 cannot be the same as the treating fluid because the light fluid must have a density less than the ball sealer density to insure that the balls are kept below the perforations through which treating fluid is to flow.
  • interval 14 After interval 14 has been suitably treated, pressure of the wellhead is released and the differential pressure from the formation toward the wellbore causes the ball sealers to be released from the perforations 16. Additional intervals (not shown) may then be selectively treated according to this invention by introducing additional dense fluid 20 into the well to float the ball sealers to a position above the perforations of the next higher interval to be temporarily plugged and below the perforation of the next higher interval to be treated, introducing additional light fluid to replenish the light fluid lost during prior treating step and then injecting additional treating fluid to treat the next higher interval or intervals above the ball sealers.
  • ball sealers, dense fluid 20, and light fluid 21 in the above embodiment were introduced into the casing sequentially, it should be understood that the ball sealers 22 and fluids 20 and 21 may be introduced in the casing in any order, and may be introduced concurrently. In another embodiment, dense fluid 20 and light fluid 21 may be pumped into the well simultaneously with ball sealers subsequently introduced into the casing at the wellhead by a dispenser or other suitable injection device.
  • the ball sealers positioned in the well according to this invention do not interfere with the injection of treating fluids during multi-stage treatment of a formation.
  • the ball sealers disposed in the well between intervals 14 and 15 will seat upon the perforations 16 which have fluid flowing therethrough with 100% efficiency. That is, each and every ball sealer will seat and plug a perforation 16 as long as there is a perforation 16 through which fluid is flowing. If the low density fluid 21 flows through the lower perforations 16, the ball sealers will seat.
  • a predictable diversion process will occur because the number of perforations plugged by the ball sealers will be equal to the number of ball sealers injected into the casing. Therefore, the number of ball sealers to use in carrying out the present invention depends upon the number of perforations to be restricted. Because of the high seating efficiency, an excess of such ball sealers normally will be unnecessary.
  • the dense fluid 20 will generally have a density of at least 1.0 g/cc and the light fluid 21 will generally have a density less than about 0.8 g/cc.
  • the density of the ball sealers will therefore generally range from about 0.8 to 1.1 g/cc.
  • the present invention possesses a number of advantages over procedures now used in multi-zone treatment or stimulation techniques.
  • any zone can be treated with any desired treatment volume with essentially no loss in efficiency from fluid being lost to perforations below the zone to be treated.
  • the advantages of the present invention over methods previously used to exclude intervals from receiving injection fluids include simplicity because no expensive equipment is required to perform the process and flexibility because changes in injection elevation may be made quickly and cheaply.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
  • Application Of Or Painting With Fluid Materials (AREA)
  • Sealing Material Composition (AREA)
  • Pretreatment Of Seeds And Plants (AREA)
  • Cereal-Derived Products (AREA)
  • Pipe Accessories (AREA)
US05/850,879 1977-11-14 1977-11-14 Selective wellbore isolation using buoyant ball sealers Expired - Lifetime US4139060A (en)

Priority Applications (12)

Application Number Priority Date Filing Date Title
US05/850,879 US4139060A (en) 1977-11-14 1977-11-14 Selective wellbore isolation using buoyant ball sealers
CA308,522A CA1081608A (en) 1977-11-14 1978-08-01 Selective wellbore isolation using buoyant ball sealers
AU38864/78A AU514250B2 (en) 1977-11-14 1978-08-14 Selective wellbore, isolation with buoyant ball sealers
NO783267A NO152467C (no) 1977-11-14 1978-09-27 Fremgangsmaate til behandling av en formasjon rundt en broenn
NLAANVRAGE7810001,A NL174752C (nl) 1977-11-14 1978-10-03 Werkwijze voor het selectief aan een behandeling met een vloeistof onderwerpen van ondergrondse formaties.
MX175290A MX149571A (es) 1977-11-14 1978-10-19 Mejoras en metodo para tratar selectivamente una formacion subterranea
DE2848972A DE2848972C2 (de) 1977-11-14 1978-11-11 Verfahren zur selektiven Behandlung unterirdischer Formationen
GB8128472A GB2085512B (en) 1977-11-14 1978-11-14 A ball sealer having a core of syntactic foam and a polyurethane cover
GB7844467A GB2007745B (en) 1977-11-14 1978-11-14 Selective wellbore isolation using buoyant ball sealers
NO83833401A NO154403C (no) 1977-11-14 1983-09-21 Tetningskule for stengning av perforeringer i et foringsroer.
MY112/85A MY8500112A (en) 1977-11-14 1985-12-30 Treating a formation having a wellbore using buoyant ball sealers for plugging lower perforations in casing well
MY117/85A MY8500117A (en) 1977-11-14 1985-12-30 A ball sealer having a core of syntatic foam and a polyurethane cover

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US05/850,879 US4139060A (en) 1977-11-14 1977-11-14 Selective wellbore isolation using buoyant ball sealers

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US4139060A true US4139060A (en) 1979-02-13

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US (1) US4139060A (xx)
AU (1) AU514250B2 (xx)
CA (1) CA1081608A (xx)
DE (1) DE2848972C2 (xx)
GB (2) GB2007745B (xx)
MX (1) MX149571A (xx)
MY (2) MY8500117A (xx)
NL (1) NL174752C (xx)
NO (2) NO152467C (xx)

Cited By (24)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE2924610A1 (de) * 1978-07-03 1980-01-24 Exxon Production Research Co Verfahren zur behandlung unterirdischer formationen sowie kugeldichtungen zur durchfuehrung des verfahrens
US4244425A (en) * 1979-05-03 1981-01-13 Exxon Production Research Company Low density ball sealers for use in well treatment fluid diversions
US4421167A (en) * 1980-11-05 1983-12-20 Exxon Production Research Co. Method of controlling displacement of propping agent in fracturing treatments
US4488599A (en) * 1982-08-30 1984-12-18 Exxon Production Research Co. Method of controlling displacement of propping agent in fracturing treatments
US4505334A (en) * 1983-09-06 1985-03-19 Oil States Industries, Inc. Ball sealer
US4648453A (en) * 1985-11-18 1987-03-10 Exxon Production Research Co. Process for remedial cementing
US4753295A (en) * 1984-11-19 1988-06-28 Exxon Production Research Company Method for placing ball sealers onto casing perforations in a deviated portion of a wellbore
US4881599A (en) * 1986-10-03 1989-11-21 Petroleo Brasileiro S.A. - Petrobras Mechanical system for diversion in the acidizing treatment of oil formations
US5309995A (en) * 1991-03-05 1994-05-10 Exxon Production Research Company Well treatment using ball sealers
US5507342A (en) * 1994-11-21 1996-04-16 Mobil Oil Corporation Method of selective treatment of open hole intervals in vertical and deviated wellbores
WO1999010623A1 (en) * 1997-08-26 1999-03-04 Exxonmobil Upstream Research Company Stimulation of lenticular natural gas formations
US6394184B2 (en) 2000-02-15 2002-05-28 Exxonmobil Upstream Research Company Method and apparatus for stimulation of multiple formation intervals
US6543538B2 (en) 2000-07-18 2003-04-08 Exxonmobil Upstream Research Company Method for treating multiple wellbore intervals
US6672405B2 (en) 2001-06-19 2004-01-06 Exxonmobil Upstream Research Company Perforating gun assembly for use in multi-stage stimulation operations
US20050230117A1 (en) * 2004-04-16 2005-10-20 Wilkinson Jeffrey M Method of treating oil and gas wells
US20060021753A1 (en) * 2004-07-30 2006-02-02 Key Energy Services, Inc. Method of Pumping an "In-the-Formation" Diverting Agent in a Lateral Section of an Oil and Gas Well
US20070062690A1 (en) * 2005-09-16 2007-03-22 Witcher Harold L Packer washout assembly
US20090288833A1 (en) * 2008-05-20 2009-11-26 Halliburton Energy Services, Inc. System and methods for constructing and fracture stimulating multiple ultra-short radius laterals from a parent well
US20100147866A1 (en) * 2008-12-15 2010-06-17 Weir Spm, Inc. Ball Injector
US20120067447A1 (en) * 2009-04-16 2012-03-22 Nicholas John Ryan Delivery method and compositions
US8905139B2 (en) 2009-04-24 2014-12-09 Chevron U.S.A. Inc. Blapper valve tools and related methods
CN108756749A (zh) * 2013-07-25 2018-11-06 哈里伯顿能源服务公司 用于使外圆角组件偏转的方法
US10760370B2 (en) 2016-12-16 2020-09-01 MicroPlug, LLC Micro frac plug
US11795377B2 (en) 2015-12-21 2023-10-24 Schlumberger Technology Corporation Pre-processed fiber flocks and methods of use thereof

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CA1240615A (en) * 1984-11-19 1988-08-16 Gerard A. Gabriel Method for placing ball sealers onto casing perforations in a deviated wellbore
CA2693676C (en) 2010-02-18 2011-11-01 Ncs Oilfield Services Canada Inc. Downhole tool assembly with debris relief, and method for using same
US8905133B2 (en) 2011-05-11 2014-12-09 Schlumberger Technology Corporation Methods of zonal isolation and treatment diversion
US10808497B2 (en) 2011-05-11 2020-10-20 Schlumberger Technology Corporation Methods of zonal isolation and treatment diversion
CA2798343C (en) 2012-03-23 2017-02-28 Ncs Oilfield Services Canada Inc. Downhole isolation and depressurization tool
US10001613B2 (en) 2014-07-22 2018-06-19 Schlumberger Technology Corporation Methods and cables for use in fracturing zones in a well
US10738577B2 (en) 2014-07-22 2020-08-11 Schlumberger Technology Corporation Methods and cables for use in fracturing zones in a well

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Cited By (39)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE2924610A1 (de) * 1978-07-03 1980-01-24 Exxon Production Research Co Verfahren zur behandlung unterirdischer formationen sowie kugeldichtungen zur durchfuehrung des verfahrens
US4407368A (en) * 1978-07-03 1983-10-04 Exxon Production Research Company Polyurethane ball sealers for well treatment fluid diversion
US4244425A (en) * 1979-05-03 1981-01-13 Exxon Production Research Company Low density ball sealers for use in well treatment fluid diversions
US4421167A (en) * 1980-11-05 1983-12-20 Exxon Production Research Co. Method of controlling displacement of propping agent in fracturing treatments
US4488599A (en) * 1982-08-30 1984-12-18 Exxon Production Research Co. Method of controlling displacement of propping agent in fracturing treatments
US4505334A (en) * 1983-09-06 1985-03-19 Oil States Industries, Inc. Ball sealer
US4753295A (en) * 1984-11-19 1988-06-28 Exxon Production Research Company Method for placing ball sealers onto casing perforations in a deviated portion of a wellbore
US4648453A (en) * 1985-11-18 1987-03-10 Exxon Production Research Co. Process for remedial cementing
US4881599A (en) * 1986-10-03 1989-11-21 Petroleo Brasileiro S.A. - Petrobras Mechanical system for diversion in the acidizing treatment of oil formations
US5309995A (en) * 1991-03-05 1994-05-10 Exxon Production Research Company Well treatment using ball sealers
US5507342A (en) * 1994-11-21 1996-04-16 Mobil Oil Corporation Method of selective treatment of open hole intervals in vertical and deviated wellbores
WO1999010623A1 (en) * 1997-08-26 1999-03-04 Exxonmobil Upstream Research Company Stimulation of lenticular natural gas formations
US5890536A (en) * 1997-08-26 1999-04-06 Exxon Production Research Company Method for stimulation of lenticular natural gas formations
AU736644B2 (en) * 1997-08-26 2001-08-02 Exxonmobil Upstream Research Company Stimulation of lenticular natural gas formations
US6394184B2 (en) 2000-02-15 2002-05-28 Exxonmobil Upstream Research Company Method and apparatus for stimulation of multiple formation intervals
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MX149571A (es) 1983-11-25
NL174752B (nl) 1984-03-01
GB2007745B (en) 1982-11-17
NO154403C (no) 1986-09-10
DE2848972C2 (de) 1983-01-27
NL174752C (nl) 1984-08-01
NO152467B (no) 1985-06-24
NO783267L (no) 1979-05-15
MY8500117A (en) 1985-12-31
MY8500112A (en) 1985-12-31
AU514250B2 (en) 1981-01-29
NO154403B (no) 1986-06-02
CA1081608A (en) 1980-07-15
DE2848972A1 (de) 1979-05-17
NO152467C (no) 1985-10-02
AU3886478A (en) 1980-02-21
GB2085512A (en) 1982-04-28
GB2007745A (en) 1979-05-23
GB2085512B (en) 1982-10-20
NO833401L (no) 1979-05-15
NL7810001A (nl) 1979-05-16

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